Development of enhanced nanocomposite preformed particle gels for conformance control in high-temperature and high-salinity oil reservoirs

Durán-Valencia, C.; Bai, Baojun; Reyes, Horacio; Fajardo-Lopez, Romina; Barragán-Aroche, Fernando; López-Ramírez, Simón

doi:10.1038/pj.2013.99

Cited by 66 publications

(34 citation statements)

References 26 publications

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“…The effects of temperature on swelling ratio have been investigated by many researchers. At higher temperatures, amide groups (−CONH 2 ) will convert to acidic carboxylic groups (−COOH) by hydrolysis . Our laboratory results indicate that swelling capacity of PPGs 23, 24, 25, and 26 increases with an increase in temperature up to 110 °C.…”

Section: Resultsmentioning

confidence: 67%

“…Our laboratory results indicate that swelling capacity of PPGs 23, 24, 25, and 26 increases with an increase in temperature up to 110 °C. However at higher temperatures, water expulsion will reduce the volume of the particle gel due to gel syneresis and hydrolysis of the amide groups will enhance posterior ionic cross‐linking with metal cations present in the water . Molecular structure degradation due to thermal effect is also common .…”

Section: Resultsmentioning

confidence: 99%

“…Gel treatment is one of the most important methods to correct reservoir heterogeneity . However, some gel conformance control methods have significant disadvantages: the bulk gel process usually requires high concentration of both polymer and cross‐linker chemicals to make a strong gel, the gelation time and physical properties are difficult to predict, sequential injection of the gelant into the reservoir probably makes a chromatography separation in gelant composition, and most of them are not stable at more extreme reservoir conditions with high temperature .…”

Section: Introductionmentioning

confidence: 99%

“…Most PPGs‐based treatments have been successfully applied in mature fields, but there have been very few experimental reports on understanding the effects of functional groups and reservoir conditions on PPGs thermo‐chemical stability . Water expulsion will reduce the volume of the particle gel in reservoirs with high temperature, salinity, and hardness due to gel syneresis and hydrolysis of the amide groups and posterior ionic cross‐linking with metal cations in the water . High salinity brine used to prepare the PPGs results in a lower swelling ratio, and higher swollen particle strength.…”

Section: Introductionmentioning

confidence: 99%

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Improvement in thermo‐chemical stability of nanocomposite preformed particle gels for conformance control in harsh oil reservoir conditions

Saghafi¹,

Naderifar

Gerami

et al. 2016

Can J Chem Eng

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Gel treatment is one of the most promising technologies to improve conformance control in heterogeneous reservoirs. In this paper, new enhanced preformed particle gels (PPGs) are introduced for conformance control in high‐temperature and high‐salinity oil reservoirs. The thermo‐chemical stability of this product is due to the incorporation of a new monomer, N,N‐dimethyl acrylamide (DA), to the structure of the last well‐known nano‐composite PPGs. Four species, N,N‐dimethyl acrylamide, 2‐acrylamido‐2‐methylpropane sulphonic sodium salt (AMPSNa), acrylamide (AM), and N‐vinylpyrrolidone (NVP) monomers, were used to synthesize these PPGs via free radical cross‐linking polymerization at room temperature using N,N‐methylenebis (acrylamide) as a cross‐linker. The mechanical properties of these new classes of PPGs were enhanced by adding the nano‐clay montmorillonite Na+. A temperature stability agent was also used to make these special PPGs compatible with high temperature and salinity reservoir conditions. A systematic study on PPGs preparation was conducted to improve PPGs stability for harsh reservoir conditions that exist in Persian Gulf oil reservoirs (a temperature of 145 °C and a water total dissolved solid of 225 000 mg/L). PPGs prepared with 0.30 g/g (30 wt%) of a 2:1:1:2 molar mass ratio of AM, DA, NVP, and AMPSNa could be completely stable for the mentioned conditions. Rheological behaviours of these PPGs were investigated and a mathematical model for prediction of storage modulus up to onset of elastic to viscous phase was presented. The results of this study reveal useful insights about the selection of appropriate material for successful conformance control in the heterogeneous reservoirs.

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Section: Resultsmentioning

confidence: 67%

Section: Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

Improvement in thermo‐chemical stability of nanocomposite preformed particle gels for conformance control in harsh oil reservoir conditions

Saghafi¹,

Naderifar

Gerami

et al. 2016

Can J Chem Eng

View full text Add to dashboard Cite

show abstract

“…However, a number of undeveloped reservoirs or low-working-degree reservoirs still exist in the medium-and low-permeable layers of reservoirs. [6][7][8][9][10][11][12][13] However, as the reservoir structure becomes increasingly complex after entering the high-or ultrahigh-water-cut stage, the existing general profile control technology hardly meets the actual needs of reservoirs. 4,5 Profile control is one of the most effective methods to improve the development effect and oil recovery of highly heterogeneous reservoirs in the high-water-cut stage by using chemical agents and related technology.…”

mentioning

confidence: 99%

Migration characteristics and deep profile control mechanism of polymer microspheres in porous media

Niu

2019

Energy Science & Engineering

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The performance and migration characteristics of polymer microspheres in porous media and the mechanism of deep profile control for oil displacement were studied by theoretical analysis, instrument detection, and physical simulation to further improve oil recovery. Polymer microspheres were expansive in water and nonexpansive in oil. The polymer microspheres with short expansion times possessed excellent mechanical shear resistance. According to the matching factor (Ra), resistance factor, and residual resistance factor, the migration of polymer microspheres in porous media was divided into four periods: transportation (Ra > 2.41), bridging plugging (1 < Ra < 2.41), elastic plugging (Ra < 1), and fatigue (microsphere breakage). The resistance factor and residual resistance factor of the polymer microspheres during the bridging and elastic plugging periods were larger than those during other periods. The deep oil displacement profile can be controlled by adjusting the occurrence positions (distance from the injection end) of these two periods. Increasing the injection rate during the transportation and bridging plugging periods and decreasing the injection rate during the elastic plugging period made elastic plugging occur farther from the injection end while maintaining the resistance factor and residual resistance factor at high levels. Aimed at the remaining oil accumulation area, the optimal profile control depth of oil displacement (distance from the injection end) of polymer microspheres in porous media can be regulated by changing the injection rate to enhance oil recovery. The simultaneous migration and expansion of polymer microspheres is the main mechanism of microsphere fluid diversion in porous media.

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Preparation and profile control evaluation of core‐shell structure and surface‐hydrophobic modified polyacrylamide microsphere

Wang

Chen

Wang

et al. 2022

J of Applied Polymer Sci

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Polyacrylamide (PAM) microsphere has been widely used in the field of profile control to reduce water cut in heterogeneous reservoirs. However, its mechanical strength and plugging ability are still needed to be improved. In this paper, a core‐shell structure and surface‐hydrophobic polyacrylamide M‐P(AM‐PEP) microsphere was prepared by using acrylamide (AM), block polyether macro monomer (PEP) and modified SiO2 with double bond on the surface as monomers through dispersion polymerization. After the optimization of synthesis conditions, the results of SEM and TEM confirmed that M‐P(AM‐PEP) microsphere had the nano‐scale spherical shape and the inorganic core/polymer shell structure, while the contact angle test results showed that M‐P(AM‐PEP) microsphere had the surface‐hydrophobicity. Swelling experiments presented that the size of M‐P(AM‐PEP) microsphere can be increased by 6 times and had obvious self‐gathering behavior. The inorganic core and self‐gathering behavior are helpful for improving mechanical strength and plugging ability of PAM microsphere, respectively. Profile control and oil recovery improvement experiment showed that injecting 0.1 PV M‐P(AM‐PEP) microsphere can decrease the water cut and increase the oil recovery of 17.95%. This new microsphere could be an efficient technology for the profile control in the heterogeneous reservoir.

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Development of enhanced nanocomposite preformed particle gels for conformance control in high-temperature and high-salinity oil reservoirs

Cited by 66 publications

References 26 publications

Improvement in thermo‐chemical stability of nanocomposite preformed particle gels for conformance control in harsh oil reservoir conditions

Improvement in thermo‐chemical stability of nanocomposite preformed particle gels for conformance control in harsh oil reservoir conditions

Migration characteristics and deep profile control mechanism of polymer microspheres in porous media

Preparation and profile control evaluation of core‐shell structure and surface‐hydrophobic modified polyacrylamide microsphere

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